ECEN 615 Methods of Electric Power Systems Analysis

1. ECEN 615Methods of Electric Power Systems Analysis Lecture 7: Advanced Power Flow Prof. Tom Overbye Dept. of Electrical and Computer Engineering Texas A&M University overbye@tamu.edu

2. Announcements • Read Chapter 6 from the book • They formulate the power flow using the polar form for the Ybus elements • Homework 2 is due on Thursday September 26

3. Aggieland37 With Phase Shifters PowerWorld Case: Aggieland37_PhaseShifter

4. Large Case Phase Shifter Limits and Step Size

5. Impedance Correction Tables • With taps the impedance of the transformer changes; sometimes the changes are relatively minor and sometimes they are dramatic • A unity turns ratio phase shifter is a good example with essentially no impedance when the phase shift is zero • Often modeled with piecewise linear function with impedance correction varying with tap ratio or phase shift • Next lines give several examples, with format being (phase shift or tap ratio, impedance correction) • (-60,1), (0,0.01), (60,1) • (-25,2.43),(0,1),(25,2.43) • (0.941,0.5), (1.04,1), (1.15,2.45) • (0.937,1.64), (1,1), (1.1, 1.427)

6. Three-Winding Transformers • Three-winding transformers are very common, with the third winding called the tertiary • The tertiary is often a delta winding • Three-winding transformers have various benefits • Providing station service • Place for a capacitor connection • Reduces third-harmonics • Allows for three different transmission level voltages • Better handling of fault current

7. Three-Winding Transformers • Usually modeled in the power flow with a star equivalent; the internal “star” bus does not really exist • Star bus is often given a voltage of 1.0 or 999 kV Impedances calculated using the wye-delta transform can result in negative resistance (about 900 out of 97,000 in EI model) The winding impedances are measured between the windings with one winding shorted and the other open; for example Z12 is measured from 1 with winding 2 shorted, 3 open Image from Power System Analysis and Design, by Glover, Overbye, and Sarma 6th Edition

8. Three-Winding Transformer Example Z12 = Z1 + Z2 Z13 = Z1 + Z3 Z23 = Z2 + Z3 Hence Z1=0.5(Z12+Z13-Z23) Z2=0.5(Z12+Z23-Z13) Z3=0.5(Z13+Z23-Z12) Image from Power System Analysis and Design, by Glover, Overbye, and Sarma 6th Edition

9. Three-Winding Transformer Example, cont. Image from Power System Analysis and Design, by Glover, Overbye, and Sarma 6th Edition

10. When Transformers go Bad

11. Switched Shunts and SVCs • Switched capacitors andsometimes reactors are widely used at both the transmission and distribution levels tosupply or (for reactors)absorb discrete amounts of reactive power • Static var compensators (SVCs) are also used to supply continuously varying amounts of reactive power • In the power flow SVCs are sometimes represented as PV buses with zero real power

12. Switched Shunt Control • The status of switched shunts can be handled in an outer loop algorithm, similar to what is done for LTCs and phase shifters • Because they are discrete they need to regulate a value to a voltage range • Switches shunts often have multiple levels that need to be simulated • Switched shunt control also interacts with the LTC and PV control • The power flow modeling needs to take into account the control time delays associated with the various devices

13. Switched Shunt System Design • Because switched shunts tend to have a local impact, there needs to be a coordinated design in their implementation at the transmission level • Shunt capacitors used to raise the voltage, shunt reactors used to lower the voltage; used with LTCs and gens • Often in the transmission system they are switched manually by a system operator • The size and number of banks depends • Change in the system voltages caused by bank switching • The availability of different sizes • Cost for the associated switchgear and protection system

14. Switched Shunt Sizing • A goal with switched shunt sizing is to avoid human irritation caused by excessive changes in lighting • IEEE Std 1453-2015 gives guidance on the percentage of voltage changes as a function of time; Table 3of the standard suggests keeping the voltagechanges below about 3% • We determine analytic methods to calculate thispercentage later in the semester Image from IEEE Std. 1453-2015, “IEEE Recommended Practice for Measurement and Limits of Voltage Fluctuations and Associated Light Flicker on AC Power Systems”

15. Dynamic Reactive Capability • Switched shunts are often used to maintain adequate dynamic reactive power from generators and SVCs • FERC Order 827 (from June 2016, titled “Reactive Power Requirements for Non-Synchronous Generation”) states that the power factor of generators should be between 0.95 leading to 0.95 lagging • Hence the absolute value of the Mvar output of the machines should be no more than 31% of the MW output • Often a value substantially better for reactive reserves • Switched shunts are used to keep the generator power factor within this range

16. Area Interchange Control • The purpose of area interchange control is to regulate or control the interchange of real power between specified areas of the network • Under area interchange control, the mutually exclusive subnetworks, the so-called areas, that make up a power system need to be explicitly represented • These areas may be particular subnetworks of a power grid or may represent various interconnected systems • The specified net power out of each area is controlled by the generators within the area • A power flow may have many more areas than balancing authority areas

17. Area Interchange Control • The net power interchange for an area is the algebraic sum of all its tie line real power flows • We denote the real power flow across the tie line from bus k to bus m by Pkm • We use the convention that Pkm > 0 if power leaves node k and Pkm 0 otherwise • Thus the net area interchange Si of area i is positive (negative) if area i exports (imports) • Consider the two areas i and j that are directly connected by the single tie line (k, m) with the node k in area i and the node m in area j

18. Net Power Interchange • Then, for the complex power interchange Si, we have a sum in which Pkm appears with a positive sign; for the area j power interchange it appears with a negative sign Area i Area j k m Pkm Area i exports Pkmand Area j imports Pkm

19. Net Power Interchange • Since each tie line flow appears twice in the net interchange equations, it follows that if the power system as a distinct areas, then • Consequently, the specification of Si for a collection of (a-1) areas determines the system interchange; we must leave the interchange for one area unspecified • This is usually (but not always) the area with the system slack bus

20. Modeling Area Interchange • Area interchange is usually modeled using an outer loop control • The net generation imbalance for an area can be handled using several different approach • Specify a single area slack bus, and the entire generation change is picked up by this bus; this may work if the interchange difference is small • Pick up the change at a set of generators in the area using constant participation factors; each generator gets a share • Use some sort of economic dispatch algorithm, so how generation is picked up depends on an assumed cost curve • Min/max limits need to be enforced

21. Including Impact on Losses • A change in the generation dispatch can also change the system losses. These incremental impacts need to be included in an area interchange algorithm • We’ll discuss the details of these calculations later in the course when we consider sensitivity analysis

22. Area Interchange Example: Seven Bus, Three Area System PowerWorld Case: B7Flat

23. Example Large System Areas Each oval corresponds to a power flow area with the size proportional to the area’s generation

24. Generator Volt/Reactive Control • Simplest situation is a single generator at a bus regulating its own terminal • Either PV, modeled as a voltage magnitude constraint, or as a PQ with reactive power fixed at a limit value. If PQ the reactive power limits can vary with the generator MW output • Next simplest is multiple generators at a bus. Obviously they need to be regulating the bus to the same voltage magnitude • From a power flow solution perspective, it is similar to a single generator, with limits being the total of the individual units • Options for allocation of vars among generators; this can affect the transient stability results

25. Generator Voltage Control This exampleuses the casePSC_37Buswith a voltagecontour. Tryvarying the voltagesetpoint for the generatorat PEAR69

26. Generator Remote Bus Voltage Control • Next complication is generators at a single bus regulating a remote bus; usually this is the high side of their generator step-up (GSU) transformer • When multiple generators regulate a single point their exciters need to have a dual input • This can be implemented in the power flow for the generators at bus j regulating the voltage at bus k by changing the bus j voltage constraint equation to be (however, this does create a zero on the diagonal of the Jacobian) • Helps with power system voltage stability

27. Reactive Power Sharing Options Different softwarepackages usedifferent approachesfor allocatingthe reactive power;PowerWorld hasseveral options.

28. Reactive Power Sharing In this example, case PSC_37Bus_Varsharing,the two generators atElm345 are jointly controllingElms138

29. Generator Remote Bus Voltage Control • The next complication is to have the generators at multiple buses doing coordinated voltage control • Controlled bus may or may not be one of the terminal buses • There must be an a priori decision about how much reactive power is supplied by each bus; example allocations are a fixed percentage or placing all generators at the same place in their regulation range • Implemented by designating one bus as the master; this bus models the voltage constraint • All other buses are treated as PQ, with the equation including a percent of the total reactive power output of all the controlling bus generators

30. Remote and Coordinated Var Control Example Here the generators at Elm345 and the one at Birch69 are jointly controlling the voltage at the Lemon138 bus. Case is PSC_37Bus_Varsharing_MultipleBuses

31. Example of Hourly Voltage Variation Over Time

32. Power Flow Topology Processing • Commercial power flow software must have algorithms to determine the number of asynchronous, interconnected systems in the model • These separate systems are known as Islands • In large system models such as the Eastern Interconnect it is common to have multiple islands in the base case (one recent EI model had nine islands) • Islands can also form unexpectedly as a result of contingencies • Power can be transferred between islands using dc lines • Each island must have a slack bus

33. Power Flow Topology Processing • Anytime a status change occurs the power flow must perform topology processing to determine whether there are either 1) new islands or 2) islands have merged • Determination is needed to determine whether the island is “viable.” That is, could it truly function as an independent system, or should the buses just be marked as dead • A quite common occurrence is when a single load or generator is isolated; in the case of a load it can be immediately killed; generators are more tricky

34. Topology Processing Algorithm • Since topology processing is performed often, it must be quick (order n ln(n))! • Simple, yet quick topology processing algoritm • Set all buses as being in their own island (equal to bus number) • Set ChangeInIslandStatus true • While ChangeInIslandStatus Do • Go through all the in-service lines, setting the islands for each of the buses to be the smaller island number; if the island numbers are different set ChangeInIslandStatus true • Determine which islands are viable, assigning a slack bus as necessary This algorithm does depend on the depth of the system

35. Example of Island Formation This option allows some islandsto not have a power flow solution Splitting large systems requires a careful consideration of the flow on the island tie-lines as they are opened

36. Bus Branch versus Node Breaker • Due to a variety of issues during the 1970’s and 1980’s the real-time operations and planning stages of power systems adopted different modeling approaches Real-TimeOperations Use detailed node/breaker model EMS system as a set of integrated applications and processes Real-time operating system Real-time databases Planning Use simplified bus/branch model PC approach Use of files Stand-alone applications • Entire data sets and software tools developed around these two distinct power system models

37. Google View of a 345 kV Substation

38. Example of Using a Disconnect to Break Load Current